Method for processing signals in a cement bong logging tool

ABSTRACT

A longitudinally segmented acoustic transducer for a cement bond logging (CBL) tool having a plurality of adjoining PZT ring-like segments driven synchronously in parallel by one or more pulses and caused to vibrate in an anti-resonant mode, substantially below the resonant frequency of an individual segment when used in a transmitting application. When used in a receiving application, each of the plurality of transducer rings are caused to vibrate by acoustic signals detected by the transducer array, also in an anti-resonant mode. High speed digital signal processing enables on-depth, high quality data for all azimuths at each depth to be obtained, processed, normalized and either sent to the surface in real time for each 20 Hz firing cycle, as the CBL tool is pulled toward the surface, or stored in a memory module in digital form for later retrieval. Built-in calibration factors used for normalizing the output signals to the operating conditions of use may be accessed at any time.

CROSS REFERENCE TO RELATED APPLICATIONS

The present U. S. Patent Application is related to co-pending U. S.Patent Application entitled SONIC INSTRUMENTATION APPARATUS AND METHODFOR CEMENT BOND LOGGING, and also to co-pending U. S. Patent Applicationentitled METHOD FOR NORMALIZING SIGNALS IN A CEMENT BOND LOGGING TOOL,both filed by the same applicant on the same date as the presentapplication.

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention generally relates to instrumentation for loggingconditions in down hole formations and, more particularly to transducerdesign and uses thereof in acoustic logging instrumentation. Theacoustic transducer designs disclosed herein may be adapted to a varietyof applications, including, for example, cement bond logging.

2. Background of the Invention and Description of the Prior Art

The use of piezoelectric materials such as a polycrystaline form of leadtitanate or lead zirconate titanate, sometimes referred to as “PZT”material, has long been known. This material is generally formed as acontinuous ceramic element, usually cylindrical in shape and sized tofit within the dimensions of a cement bond logging tool. Such tools areavailable in various diameters for use with well casings typically usedin oil and gas drilling operations. Other shapes may be used in somelogging tool instrumentation, depending upon the particular application.As is well known, these piezoelectric, ceramic PZT elements, accordingto their dimensions, have characteristic resonant frequencies. A givenelement or crystal may have more than one mode of vibration in which itbehaves in accordance with its piezoelectric property. The crystal mayvibrate in the presence of an electric field alternating at or near theresonant frequency of the crystal when imposed across the crystal. Or,the crystal may produce an alternating voltage in the presence ofsufficient mechanical stress at or near the resonant frequency of thecrystal. The ceramic crystal is usually coated on two opposing surfaceswith an electrical conductor such as silver to which electrodes may beattached for connection to electronic circuitry. Thus, the crystal maybe caused to vibrate at its resonant frequency by application of asuitable excitation signal applied to the two electrodes. Conversely,the crystal may vibrate in the presence of an acoustic disturbance orwave and generate an alternating electric voltage between the twoelectrodes.

In conventional cement bond logging tools, a cylindrical piezoelectriccrystal having dimensions suited to behave in a predictable manner at achosen frequency of resonance, may be used in both transmittingtransducers and receiving transducers. In a transmitter, the crystal isexcited by an electrical signal, for example 20 KHz, and caused tovibrate at that frequency, emitting acoustic energy into thesurroundings—much as an antenna would. In a receiver, the crystal, tunedaccording to its dimensions to vibrate at the same 20 KHz frequency,produces an alternating 20 KHz voltage across its terminals when it isin the presence of the acoustic signal generated by the transmitter. Thereceiver thus acts as a sensor, responding to the acoustic energy thathas traveled through the surroundings of the instrument containing thetransducers.

The surroundings may include the well casing, the cement in the borehole that surrounds the well casing, and the nearby rock formationthrough which the borehole has been drilled. The acoustic energy sensedby the receiving transducer is conveyed by the acoustic waveform as itis modified by attenuation, reflection, refraction and interference thatmay be encountered by the signal along the particular path between thetransmitter and the receiver. Typically, the paths taken by thetransmitted acoustic signal may include (a) the body of the loggingtool; (b) the fluid in the well casing; (c) the well casing; (d) thecement or any other materials in the well outside of the well casing;and (e) the formation or lithography through which the well is bored.Operators of the surface instrumentation coupled to the logging toolsensor, by observing the received signal, may thus obtain informationabout the well casing, the cement bond and the surrounding lithographyby recording and interpreting the received acoustic signal. The signalobtained from the receiver is typically processed to preserve essentialinformation and formatted for display at the surface.

Operation of the cement bond logging tools must occur in some highlychallenging environments. For example, the temperatures in a well mayreach 350 to 400 degrees Fahrenheit. Further, the pressures in the wellat depths on the order of many thousands of feet may reach 20,000 poundsper square inch (psi). These environmental conditions impose severestresses upon the electronics and the mechanical structures of theinstrument. Further, conventional PZT elements typically function mostefficiently at or near resonance, to avoid the effects of spuriousvibrations that can interfere with the intended signals, thus limitingtheir usefulness as transducers. For example, the crystals oftengenerate harmonics of the desired frequency, which can result inintermodulation products within the band of interest near thefundamental or desired signal. In addition, operation of the crystal atonly one frequency limits the utility of the transducers to the use ofonly the one frequency.

Other aspects of prior art logging tools that limit their utility andefficiency include the following. The processing of the data signalstends to be relatively slow in comparison to the amount of data that canbe provided by the transducer. At the rates the tool is typically pulledtoward the surface while taking the data, the data “packet” from each ofthe usual eight, radially (i.e., circumferentially) arranged sectors ofthe transducer must be transmitted to the surface with a delay imposedbetween the data for each sector. Thus, the data provided represents theconditions at a sequence of helically positioned sites along the outsideof the well casing. Thus, no two adjoining data “packets” occur at thesame depth or azimuth, and no complete sets of data “packets” provideinformation about the complete circumference, in all eightequally-spaced azimuth directions, of the well casing at a single depth.The result is that the data only represents a small and ofteninsufficient sampling of the cement bond as the tool is pulled upward.

Moreover, because of the need to limit the upward rate, infeet-per-minute, that the tool is pulled toward the surface so that anadequate amount of data is obtained, substantial time is required toproduce a complete cement bond log. Additional time is required just insetting up the instrument for operation. Especially time consuming isthe time needed to calibrate the instrument for the particular loggingoperation. As is well known, the wire line used to support the loggingtool in the well casing is a very long conductor having a largedistributed reactive impedance characteristic in addition to the DCresistance of the conductor in the wire line. When the wire line is usedto transmit analog signals to the surface instrumentation, this compleximpedance and the length of the wire line must be compensated andusually involves tedious adjustments of the gain of each of the eight ormore analog preamplifiers in the logging tool. Further, the particularadjustments are usually applicable only for the conditions existing atthe time these adjustments are made because they are subject to beinginvalid as the logging tool is moved to another location, used withanother surface vehicle, the temperature or other conditions in the wellcasing change, etc. In some logging tools, when a wire known as a“slickline” is used—simply a wire for supporting the tool that is notalso used to transmit the data—the data in digital form may be stored ina memory device in or attached to the logging tool and accessed afterthe tool is returned to the surface.

The foregoing disadvantages and inefficiencies are substantiallyovercome by the features of the present invention to be described hereinbelow.

SUMMARY OF THE INVENTION

Accordingly, a longitudinally segmented acoustic transducer for a cementbond logging (CBL) tool is disclosed comprising a thin-walledpiezoelectric cylinder divided longitudinally (axially) into a pluralityof band-like transducer rings separated by resilient circular spacersdisposed between proximate edges of each pair of transducer ringsthereby forming a transducer array. When used in a transmittingapplication, the plurality of transducer rings are driven synchronouslyin parallel by one or more pulses provided by the output of a pulsegenerator and caused to vibrate in an anti-resonant mode, that is, at afrequency substantially below the resonant frequency of an individualtransducer ring. When used in a receiving application, each of theplurality of transducer rings are caused to vibrate by acoustic signalsdetected by the transducer array, and in an anti-resonant mode at afrequency substantially below the resonant frequency of each individualtransducer ring in the transducer array.

In another aspect, an acoustic logging tool is provided comprising atubular housing supported in a well casing and having at least atransmitting section and first and second receiver sections spacedlongitudinally from the transmitting section by predetermined first andsecond distances wherein at least one of the first and second receiversections is configured as an acoustic transducer having a thin-walled,piezoelectric cylinder divided axially into a plurality of band-liketransducer rings separated by resilient circular spacers disposedbetween proximate edges of each pair of transducer rings thereby forminga transducer array.

In another aspect of the invention, there is provided an acousticlogging tool, comprising a tubular housing supported in a well casingand having at least a transmitting section and first and second receiversections spaced longitudinally from the transmitting section bypredetermined first and second distances wherein a transmitter sectionconfigured as an acoustic transducer having a thin-walled, piezoelectriccylinder divided axially into a plurality of band-like transducer ringsseparated by resilient circular spacers disposed between proximate edgesof each pair of transducer rings thereby forming a transducer array.

In another aspect of the invention, a method is provided for processingelectrical signals produced by a longitudinally segmented acousticreceiving transducer in a logging tool, wherein synchronizing pulses areissued to the longitudinally segmented receiving transducer at apredetermined repetition rate and wherein the transducer output signalsare processed at high speed in digital signal processing circuitry toprovide signals normalized in real time according to built-incalibration factors and having a high signal-to-noise ratio and a highdegree of clarity, thereby extending the usable range of data that issent to the surface instrumentation.

In yet another aspect of the invention, a method is provided fornormalizing transducer signals produced by an acoustic receiver in alogging tool having at least one longitudinally segmented receivingtransducer comprising the steps of: coupling the electrical outputsignals of the parallel-connected transducer rings to a digital signalprocessing circuit to be digitized and stored in memory in the loggingtool; and normalizing the digitized electrical output signals, whereinthe step of normalizing comprises the steps of initializing circuitry inthe logging tool for executing a normalization program upon apredetermined sequence of transmitter excitation signals; executing thenormalization program to produce digital gain factors based on anaverage value N of a plurality of representative samples of a receivedsignal; and obtaining a digital gain factor for use with each channel ofthe digital signal processing circuit in the logging tool.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a cement bond logging tool suspended in acement-bonded well casing according to one embodiment of the presentinvention;

FIG. 2 illustrates a cylindrical piezoelectric transducer arrayconfigured as eight adjoining pairs of sectors, radially defined andarranged, for use in the embodiment of FIG. 1;

FIG. 3A illustrates a cylindrical piezoelectric transducer arrayconfigured as four adjoining cylindrical segments, axially defined andarranged according to the present invention, for use in the embodimentof FIG. 1;

FIG. 3B illustrates an amplitude vs. frequency graph of the responses ofa non-segmented cylindrical piezoelectric resonator having a diameter of1.50 inches and a length of 1.00 inch;

FIG. 3C illustrates an amplitude vs. frequency graph of the responses ofa longitudinal segment of a cylindrical piezoelectric resonator having adiameter of 1.50 inches and a length of 0.375 inch;

FIG. 4 illustrates a cylindrical piezoelectric transducer arrayconfigured as eight adjoining pairs of sectors, radially defined andarranged within four adjoining cylindrical segments, axially defined andarranged according to the present invention, for use in the embodimentof FIG. 1;

FIGS. 5A and 5B illustrate a comparison of an output waveform of asegmented transducer (FIG. 5A) according to the present invention asshown in the embodiment of FIG. 3A, with a conventional prior artnon-segmented transducer (FIG. 5B);

FIGS. 6A and 6B illustrate a comparison of a Variable Density Log (VDL)of the output waveform of a segmented transducer according to thepresent invention (FIG. 6A), with the VDL of a conventional prior artnon-segmented transducer (FIG. 6B);

FIG. 7 illustrates a block diagram of the signal processing circuitryfor the piezoelectric transducers according to an embodiment of thepresent invention;

FIG. 8 illustrates a simplified schematic diagram of the transmitterboard portion of the block diagram of FIG. 7;

FIG. 9 illustrates a block diagram of the control board portion of theblock diagram of FIG. 7;

FIG. 10 illustrates a flow chart of one embodiment of a process fornormalizing a cement logging tool according to the present invention foruse in the system of FIG. 7 using the transducer of FIG. 3A;

FIGS. 11A and 11B illustrate a flow chart of one embodiment of a signalprocessing method according to the present invention for use in thesystem of FIG. 6 using the transducer of FIG. 3A;

FIG. 12 illustrates an amplitude vs. time graph of the complete sequenceof signal outputs occurring in each 50 millisecond interval from thesegmented transducers according to the present invention;

FIG. 13 illustrates a set of output waveform graphs from a single GUIdisplay of the near (WVF3FT), far (WVF5FT), the eight radial sectors(WVFS 1, 2, . . . , 8), and the calibration signal (WVFCAL) from a CBLtool using the segmented transducers according to the present invention;

FIG. 14 illustrates an amplitude vs. time graph of the time relationshipof the excitation of the transmitting transducer, the sync pulsepreceding transmission of the data to the surface, and the near (3 foot)and far (5 foot) receiving transducers of a CBL tool using the segmentedtransducers according to the present invention; and

FIGS. 15A, 15B, and 15C illustrate a typical VDL (“Z axis” plot) in FIG.16A together with a corresponding cement map in FIG. 16B, whereindifferent colors or shading densities represent different cementdensities, and an amplitude vs. time graph in FIG. 15C of the signalrepresenting the density information of FIG. 15B.

DETAILED DESCRIPTION OF THE INVENTION

For the purposes of this detailed description several terms are definedas follows. The basic geometric form of many transducers used indown-hole logging tools is a cylinder having a longitudinal axis definedthrough the center of the cylinder and a radius with respect to thisaxis that defines the outer and inner surfaces. Elements of thetransducers are typically disposed in or on the outer portions of thecylindrical form. In the prior art, it is known to arrange theseelements circumferentially or azimuthally around the cylindrical form,often with equal spacings and, correspondingly, equal radial angles,between the adjacent elements. In the present description, theseelements will be identified as radial sectors of the transducer.

In the present invention to be described, the transducer elements may besubdivided and arranged in the direction of the longitudinal axis. Theindividual subdivisions, which may be placed adjacent to each other orseparated by a thin intervening ring or washer structure, thus resembleshortened cylindrical elements having a band-like or ring-likeconfiguration, assembled along and centered on the same longitudinalaxis. Such transducer elements are identified as longitudinal or axialsegments of the transducer.

In one embodiment to be described in FIG. 3A herein below, a transduceris configured as a cylindrical segmented transducer formed of anassembly of several adjoining segments. In an alternate embodiment to bedescribed in FIG. 4, a cylindrical transducer may be subdivided bothradially into sectors and axially into segments. As will be appreciatedby persons skilled in the art, a segmented piezo electric, cylindricaltransducer of a given overall length that is subdivided into two or moresegments will have different resonant characteristics, wherein eachsegment of the array will resonate at a correspondingly higher frequencythan an unsegmented transducer of the same dimensions. If the segmentedtransducer is operated at the same frequency (or within the vicinity ofthe same frequency) as the resonant frequency of the unsegmentedtransducer of the same overall dimensions, each segment will be operatedin a anti-resonant mode well-displaced from other spectral componentsrelated to the resonant frequency of the segment. When the segments ofsuch an array are coupled together and used as either a transmitter or areceiver, this anti-resonant operation provides substantial advantagesin the performance of a cement bond logging tool, as will become evidentin the description that follows. Moreover, this improved performance isfurther enhanced through additional features incorporated into thedesign of the logging tool.

Referring to FIG. 1, there is illustrated a cement bond logging toolsuspended in a cement-bonded well casing according to one embodiment ofthe present invention. The cement bond logging tool 10 is shownsuspended by a wire line 12 in a well casing 14 in a bore hole within aformation 16. The wire line 12 is connected to the surfaceinstrumentation 28 and thus conveys data therealong, and also functionsto support the logging tool 10 within the well casing 14. In analternate embodiment to be described, the wire line 12 may beimplemented merely as a wire for supporting the logging tool 10, withoutalso being used to convey data to the surface instrumentation. In thelatter case, the data may be stored in a memory module (not shown inFIG. 1, but see, e.g., FIG. 7) attached to the logging tool 10 for laterretrieval at the surface after the logging tool is returned to thesurface. When a memory module is used, a battery supply is provided topower the module. Surrounding the well casing 14 is a cement fill 18pumped into the bore hole to seal the well against fluids being passedalong the well casing in the bore hole or becoming trapped in pocketsnext to the well casing. The integrity of the cement bond and thehydraulic seal provided thereby ensures that treatment fluids arepositioned in the targeted regions of the formation in thoseapplications where stimulation techniques such as fracturing areemployed. A well-sealed casing can also mitigate the possiblecontamination of the hydrocarbons produced by the well and contaminationof the formation through which the casing passes. A secondary benefit ofa satisfactory cement bond is to provide mechanical support for the wellcasing in the bore hole.

One of the primary purposes of the cement bond logging tool is to obtaindata for a log or record of the integrity of the bond between the wellcasing and the cement fill surrounding the casing. Cement that iswell-bonded to the casing will prevent the casing from ringing like abell, thereby damping the tendency of the casing to ring and attenuatingthe acoustic energy flowing within the casing. This attenuation enablesthe casing-conducted sound to be largely eliminated from the data sensedby the receivers. This is important because it is necessary to attenuatesound energy traveling along the well casing so that it does notinterfere with the sound picked up by the receiving transducers. Cementthat is not well-bonded allows this unwanted interference and alsoprovides pockets of the bore hole that can fill with other material suchas water, oil, gas, and other fluid substances that may impair theaccuracy of the logging operation.

Continuing with FIG. 1, the illustrated logging tool 10 includes atransmitter section 20, a first (near) receiver section 22, generallylocated three feet from the transmitter section 20, and a second (far)receiver section 24, generally located five feet from the transmittersection 20 and in the same direction from the transmitter section 20 asthe near receiver section 22. The near receiver 22 is generally used toprovide data signals about the integrity of the cement bond to the wellcasing. The far receiver 24 is generally used to provide data signalsabout the formation surrounding the bore hole, which may includeinformation about the cement bond with the formation. Each of the threesections 20, 22, and 24 include transducers for coupling sound energyinto or from the vicinity of the logging tool 10. The relative positionsof the three sections maybe inverted. In the portion of the logging tool10 between the transmitter section 20 and the near receiver section 22is a section often called the isolation section 26, sometimes referredto as the isolator sub (for subsection of the logging tool) or theisolator bar. The isolator section shown is one commonly in use, thatlengthens the acoustic path through the body of the logging tool by anarrangement of alternating slots cut into the body of the tool, thusdelaying the arrival of the sound energy traveling in the tool tominimize interference with the sound arriving at the receivertransducers via other paths of interest.

Referring to FIG. 2, there is illustrated a sectored cylindricalpiezoelectric transducer assembly or array 30 (or, alternatively,sectored array 30) configured in this illustrative embodiment as eightadjoining pairs of sectors, radially defined and arranged, for use inthe embodiment of FIG. 1. In the description herein the illustrativeembodiment of a sectored transducer is shown and described having eightradial sectors, even though it is possible for the transducer to beconstructed to have some number of sectors other than eight. The numbereight is selected because it is a number in common use in the industryand enables comparisons of the performance of the present invention withconventional transducers. However, persons skilled in the art willreadily appreciate that the principles of the present invention, insofaras they are applicable to a radially sectored transducer unit, are thusapplicable regardless of the number of radial sectors employed in aparticular transducer for a logging tool or other sonic energyinstrument. Further, implementing transducers having other numbers ofradial sectors is simply a matter of scaling the structure of thetransducer and related apparatus to accommodate the different number ofsectors.

An acoustic transducer of the configuration of FIG. 2 may be used ineither a transmitter or receiver of a logging instrument. The transducerarray 30 is formed by a single thin-walled, one-piece PZT cylinderhaving sixteen narrow, metallized electrode strips, each configured inthe manner of a single turn loop around the cylinder wall in a directionparallel to the longitudinal axis of the cylinder at each of sixteen,equally-spaced radial increments disposed at 22.5 degree intervalsaround the cylinder wall. Half of the sixteen electrode strips atalternate positions spaced radially at 45 degree intervals aredesignated as signal electrodes 40. The remaining eight electrodestrips, designated as common electrode strips 44 are also spacedradially at 45 degree intervals relative to each other, each onedisposed between and parallel to a pair of signal electrodes 40, areconnected together daisy-chain style by a set of jumpers (not visible inFIG. 2) within the mandrel structure to be described.

Disposed within the cylindrical PZT element 32 is a cylindrical mandrel34 of smaller diameter than the inside diameter of the PZT element 32.The mandrel 34 may be a machined component fabricated of aluminum, forexample. Between the inside wall of the PZT element 32 and the mandrel34 is an annulus 36 of, typically, molded silicone material that furthercontains several passages 38, disposed parallel to the longitudinal axisof the mandrel 34 and through the wall of the annulus 36 to provide forthermal expansion of the transducer array 30.

Continuing with FIG. 2, a signal lead 42 is shown connected to alternateones of the signal electrodes 40, typically at one end of the transducerarray 30. Each signal lead 42 provides an electrical output signalcorresponding to one of eight radial sectors of the transducer array 30,each radial sector in the illustrative embodiment consisting of a pairof adjacent regions demarcated around the wall of the cylindrical PZTelement 32 by the signal electrodes 40. The eight signal leads 42 alsocorrespond to one of two oppositely defined poles of the PZT element 32.The other defined pole of the transducer array 30 is defined by a set ofeight common electrodes 44. Common electrodes 44 are connected insidethe mandrel 34 to a sequence of jumper wires (not shown) that connectthe eight common electrodes 44 (that were not connected to one of theeight signal leads 42) together. Thus, the output signal from eachradial sector is provided at a signal lead 42 and the common lead 44. Inpractice, the eight signal leads 42 are connected to the respectiveinputs of eight preamplifiers in a sequence corresponding to the orderof the radial sectors around the circumference of the transducer array30.

Referring to FIG. 3A, there is illustrated a longitudinally or axiallysegmented cylindrical piezoelectric transducer array 50 (or,alternatively, segmented array 50) configured as four adjoiningcylindrical segments, axially defined and arranged according to thepresent invention, for use in the embodiment of FIG. 1 or in otherdown-hole logging instruments requiring a high performance acoustictransducer. It is intended in the description that follows that the useof the term segmented herein refers to a cylindrical acoustic transducerthat is subdivided into axial segments—providing a sequence of adjoiningrings assembled together along a common longitudinal axis, where thesubdivisions are defined along planes that are perpendicular to thelongitudinal axis. Thus, in FIG. 3A, there are shown four rings orsegments 52 positioned adjacent each other along a common longitudinalaxis of a mandrel 54 to form the segmented array 50. The four segments52 of the segmented array 50 are preferably separated by a resilientgasket 68, such as an 0-ring, at each interface between a pair ofadjacent segments 52. Although four segments are shown in FIG. 3A, theinvention disclosed herein contemplates that any number of segments maybe utilized, wherein each segment is operated in an anti-resonant mode.

Each of the segments 52 may be coated on its outside surface and itsinside surface with a metallic coating such as silver. The metalliccoating, such as typically provided by a metallized surface, provides anelectrode for connecting the transducer segment to a circuit to providefor excitation or sensing of acoustic vibrations by an individualsegment 52. Also shown in FIG. 3A, a common lead 62 is connected to acommon jumper wire 66 that is connected to the outer surface of each ofthe segments 52 of the segmented array 50 at a corresponding terminal 60disposed on the outer metallized surfaces of the segments 52. Anothersignal lead, common lead 64 is similarly connected inside the mandrel 54to a sequence of jumper wires (not shown) connected to each of the innersurface electrodes of the segments 52. Further, In the embodiment ofFIG. 3A, the electrodes on the outer wall of the segments defines onepole of the transducer and the electrodes deposited on the inner surfaceof a segment together define the opposite electric pole.

Disposed within the segmented array 50 of FIG. 3A is a cylindricalmandrel 54 of smaller diameter than the inside diameter of the segmentedarray 50. The mandrel 54 may be a machined component fabricated ofaluminum, for example. Between the inside wall of the segmented array 50and the mandrel 54 is an annulus 56 of, typically, molded siliconematerial that further contains several passages 58, disposed parallel tothe longitudinal axis of the mandrel 54 and through the wall of theannulus 56 to provide for thermal expansion of the segmented array 50.The silicone annulus 56 provides a relatively solid construction of thetransducer elements and the mandrel while isolating them acoustically.

Referring to FIG. 3B, there is illustrated an amplitude vs. frequencygraph 72 of the responses of a typical example of a non-segmentedcylindrical piezoelectric resonator 70 having a diameter of 1.50 inchesand a length of 1.00 inch. The response illustrated is characteristic ofone of two principle modes of vibration in a cylindrical PZT element orcrystal. One of the modes is in the direction of the longitudinal axisof the cylinder form (the longitudinal mode) as the vibration wavepropagates along the surface of the cylinder. The other mode is in aradial direction around the circumference of the cylinder (thecircumferential mode) as the element expands and contracts radially. InFIG. 3B, resonant frequencies occur at approximate frequencies of (A) 12KHz; (B) 26 KHz; (C) 71 KHz; and (D) 178 KHz. The frequencies at (A),(B), and (C) are believed to correspond to three different complex,longitudinally-dominant modes of vibration of this particularconfiguration. The frequency at (D) represents a resonance occurring inthe circumferential mode and is well above the usual range of interestfor use in a logging tool instrument.

Operation at around 20 KHz is favored because of the resolution itprovides for these type of applications and because it is not so subjectto the attenuation affects due to refraction boundaries in the well.Ideally, the transducer element would be resonant only at the band ofinterest. However, for small diameter tools, the transducer mustnecessarily be correspondingly smaller. This means that the resonantfrequency of the transducer element rises and the transducer is subjectto the attenuation mentioned herein above. Thus, a single, smallertransducer may become unusable. The solution provided by the presentinvention is to divide the cylindrical shell of the required diameterinto smaller lengths or segments longitudinally and to assemble severalof them together, edge-to-edge, with a resilient gasket between eachadjoining segment, to bring the overall length back to that needed forsufficient acoustic output. The resilient gasket is provided to isolatethe resonant response of each segment from the others. The severalsegments are driven in parallel when used in a transmitter, or theiroutput signals added together when used as a receiver, to provide theneeded amplitude.

Referring to FIG. 3C, there is illustrated an amplitude vs. frequencygraph 76 of the responses of a longitudinal segment of a cylindricalpiezoelectric resonator 74 having a diameter of 1.50 inches and a lengthof only 0.375 inch. From the graph, it is seen that there is a singleresonant response (A) at approximately 178 KHz, that is due to thecircumferential mode, lies well above the frequency range of interest,and has an amplitude equal to a fraction of the amplitude of the fulllength resonator. Since the lower frequency response is free ofresonances, because the responses of the longitudinal modes aretransposed to much higher frequencies (above the range of frequencies inFIG. 3C) as a result of the substantial shortening of the axial lengthof the segmented element, the segment may be driven in an anti-resonantmode at a desired frequency of, e.g., 20 KHz with no interference fromother signals or “spurs.” To accomplish this, several like segments areassembled together and driven or sensed in parallel, to reach sufficientamplitude. It will also be apparent to persons skilled in the art thatsuch a segment 74 as illustrated in FIG. 3C may be operated at otherfrequencies in the range of the anti-resonant spectrum for theparticular crystal, for example, 5 KHz to 50 KHz. Such operation atother frequencies, including operation at multiple frequencies, opensthe possibilities of new measurement capabilities for down-holeinstrumentation.

Referring to FIG. 4, there is illustrated a cylindrical piezoelectrictransducer array configured as eight adjoining pairs of sectors,radially defined and arranged within four adjoining cylindricalsegments, axially defined and arranged according to the presentinvention, for use in the embodiment of FIG. 1. The composite array 80is assembled of four individual segments 82, 84, 86, and 88, stackededge-to-edge along a common longitudinal axis with resilient gasketssuch as O rings 104, 106, and 108 placed between adjacent segments.Thus, segments 82 and 84 are separated by a resilient gasket 104,segments 84 and 86 are separated by a resilient gasket 106, and thesegments 86 and 88 are separated by the resilient gasket 108.

Further, each of the segments 82, 84, 86, 88 includes sixteen metallizedelectrodes represented by the respective electrodes 83, 85, 87, and 89that encircle the segment at equal 22.5 degree angles around thecircumference of the segment in the same manner as the electrodes 40 and44 in FIG. 2 described herein above. Each alternate pair of signalelectrodes around each segment defines a sector that includes theportion of the PZT shell between the electrodes. The electrode betweeneach alternate pair of signal electrodes is defined as a commonelectrode for the particular sector. The segments are assembled so thatthe electrodes are aligned in the direction of the longitudinal axis andconnected together by a series of leads. For example, a representativelead 90 connects between the aligned electrodes of adjoining segments 82and 84. Similarly, a lead 92 connects between the aligned electrodes ofadjoining segments 84 and 86. Similarly, a lead 94 connects between thealigned electrodes of adjoining segments 86 and 88. Finally, a signallead 96 connects the aligned electrodes to an external circuit, whichmay be the output of a transmitter driver to be described or the inputof a receiver circuit to be described. This same arrangement ofconnected electrodes and leads is utilized around the circumference ofthe transducer for each of the eight sectors. The signal leads 96 (therewill be eight of them, one for each sector, which may be color coded)may typically be bundled together into a harness or cable (not shown).Along with the eight signal leads 96 there will be a common lead orleads 97 that connect(s) together each of the common electrodes locatedbetween each of the signal electrodes of each sector, and which arefurther connected serially with the aligned common electrodes of theadjoining segments to a common terminal of the respective circuitcoupled with the transducer's composite array 80. The connection of theindividual common leads of each of the sectors and segments may beconfigured like the configuration of the signal leads 90, 92, 94, and 96but is not shown in FIG. 4 for clarity, it being readily understood bypersons skilled in the art how such connections would be implemented.

Continuing with FIG. 4, the internal construction of the composite array80 is similar to that of the transducers illustrated in FIGS. 2 and 3A.Disposed within the cylindrical PZT segments 82, 84, 86, and 88 of thecomposite array 80 is a cylindrical mandrel 100 of smaller diameter thanthe inside diameter of the cylindrical PZT segments 82, 84, 86, and 88.The mandrel 100 may be a machined component fabricated of aluminum, forexample. Between the inside wall of the cylindrical PZT segments 82, 84,86, and 88 and the mandrel 100 is an annulus 98 of, typically, moldedsilicone material that further contains several passages 102, disposedparallel to the longitudinal axis of the mandrel 100 and through thewall of the annulus 98 to provide for thermal expansion of thetransducer composite array 80. The silicone annulus 98 provides arelatively solid construction of the transducer elements and the mandrelwhile isolating them acoustically.

Referring to FIGS. 5A and 5B, there is illustrated a comparison of theoutput waveforms of a segmented transducer according to the presentinvention, such as the embodiment shown in FIG. 3A (See the waveforms ofFIG. 5A) with a conventional non-segmented transducer (See the waveformsof FIG. 5B). The waveforms appearing in FIGS. 5A and 5B are commonlyknown as “X-Y displays.” The waveform 112 shown in FIG. 5A is a voltagevs. time graph of the output signal of a receiving transducercorresponding to the acoustic signal sensed by the transducer at a depthof 9740 feet in this example. The signals shown in FIG. 5A represent theoutputs of the transducer at various depths in the well between 9650feet and 9750 feet. As is evident in the figure, the signals arecharacterized by a high degree of clarity, substantial amplitude, and aminimum of noise.

In contrast, the waveforms illustrated in FIG. 5B for the conventionalnon-segmented transducer display signals that while apparently clear,are characterized by low or insufficient amplitude, as plotted on thesame scale is the waveforms of FIG. 5A. Further, the waveforms of FIG.5B are taken under identical conditions and depths as those in FIG. 5A.The noise levels in both cases is low, in order to provide a validcomparison of the relative amplitudes. Thus waveform 114 in FIG. 5B hasan amplitude substantially smaller than the corresponding waveform 112in FIG. 5B. In the presence of electrical noise often present on thewire line, and the “road noise” typically encountered by theinstrumentation as it is pulled upward through the well casing duringdown hole logging operations, such weak signals may be masked, easilydistorted, or otherwise unresolvable with satisfactory accuracy. A moregraphic illustration of the same comparison is shown in FIGS. 6A and 6B,which present the same data in a different form.

Referring to FIGS. 6A and 6B, there is illustrated a comparison of aVariable Density Log (VDL) of the output waveform of a segmentedtransducer according to the present invention (See FIG. 6A), with theVDL of the conventional non-segmented transducer (See FIG. 6B), whereinthe VDLs of FIGS. 6A and 6B correspond to the respective outputwaveforms of FIGS. 5A and 5B. As previously stated, these graphicalimages are derived from the same acoustic signals as the waveforms inFIGS. 5A and 5B, the difference being that the data is merely displayeddifferently. As is well known, a VDL plot is the result of severalprocessing steps, which essentially consist of utilizing the positivepeak values of the signal from the transducer (i.e., the X-Y signals) tointensity modulate a bar-graph like display. Thus, the positive peaksare clipped from the signal waveform and appear as dark bars on alighter background. The lighter background represents the positions ofthe intervening negative peaks. The resulting display, called amicroseismogram, provides a graphic image of the acoustic signalrepresenting conditions next to the well casing. The detailedinterpretation of these VDL images is beyond the scope of thisdescription (but see also FIG. 14 and the description thereof), it beingsufficient in this example for the reader to note the very cleardifference in the quality and definition of the displayed image thatresults from the difference in the type of acoustic transducer used inthe logging instrument.

Referring to FIG. 7, there is illustrated a block diagram of the signalprocessing system provided for the piezoelectric transducers accordingto embodiments of the present invention. In FIG. 7 various signal pathswill be identified connecting or coupling various portions of the systemtogether. These signal paths may contain one or more distinct conductorsdepending on the particular signals being conveyed. For example, a drivesignal may require only one signal conductor and one return conductor.Conversely, a 14 bit data signal may require a 14-conductor bus toconvey the data signal. Persons skilled in the electronic arts willreadily recognize the configuration represented by the single linesidentified in FIG. 7 and described herein as sometimes referring tomultiple conductor “signal lines.” The signal processing system 130includes a control board 132, coupled to a transmitter board 134 viafiring control signal paths 136, to control the frequency of the drivesignal provided to the transmitting transducer, and 138, to control therepetition rate of the drive signal. The transmitter board includes apulse generator to develop the drive signal and a transducer driver tointerface between the pulse generator and the transmitter transducer 140via a signal line 142. The transmitter board 134 and the control board132 will be further described with FIGS. 8 and 9 respectively hereinbelow.

Continuing with FIG. 7, a receiver 144, illustrated therein as a nearreceiver 144 is coupled to a receiver board 146 via a signal path 148.Signals from the transducer coupled to the receiver 144 are amplifiedand filtered prior to outputting them to the control board 132 via asignal path 150. The received signals are sampled, digitized, and storedin memory in the circuitry of the control board 132. Prior to being sentto a line driver 152 via path 154, the stored signal data may benormalized using calibration data stored in the CBL tool memory, and, ifit is to be transmitted up the wire line 158, converted to analog form,and amplified. The line driver 152 further amplifies and conditions thesignals for transmission on the wire line 158 to the surface instruments156. In an alternate embodiment, if the data is not to transmitted upthe supporting line, i.e., to the “slickline” via line 157, it maystored in digital form in non-volatile memory in a memory module 153 viaa line 155, to be retrieved at a later time. Also, in the alternateembodiment, a battery power supply (not shown) is provided to accompanythe memory module 153. The signal processing circuitry and functionswill be further described with FIG. 9 herein below.

Referring to FIG. 8, there is illustrated a simplified schematic diagramof the transmitter board portion of the block diagram of FIG. 7. Thetransmitter board 134 (FIG. 7) includes a transmitter driver circuit 160constructed as a step up transformer 162 having first 164 and second 166primary windings, each connected to a circuit configured with a pair ofMOSFET transistors driven by signals controlled by the control board132. A secondary winding 168 couples the output transmitter driversignal 206 to the transducer portion 200 of the transmitter 160. Thetransducer portion 200 of the transmitter 160 is represented by thesymbol for a crystal, herein above described as a piezoelectric ceramicelement. The first primary winding 164, in the illustrative embodimentis formed of 78 turns and is center tapped at a node 174, forming first170 and second 172 halves of the primary winding. The center tap node174 is connected to a +80 Volt DC supply voltage to provide operatingcurrent for the drive circuit. The drain terminals of first 180 andsecond 182 MOSFET transistors, both N-type, are connected respectivelyto the ends of the first 170 and second 172 halves of the primarywinding 164 that are opposite the center tap node 174. The sourceterminals of both transistors 180 and 182 are connected to a commonterminal 198, which is connected to the ground side of the circuit.

The input signal Vin 202 coupled to the transmitter driver circuit 160in FIG. 8 is applied to first 184 and second 186 terminals, respectivelycoupled to the gate terminals of the first 180 and second 182transistors. Vin 202 may be, in the illustrative embodiment, a squarewave signal having a 50% duty cycle and a peak-to-peak voltage value offive Volts. The drive signal Vin 202 is specifically configured in thisexample as having three consecutive cycles of the driving frequency,which in this embodiment is selected at 20 Khz. Thus, each pulse cyclehas a duration of 50 microseconds (usec) and each pulse portion of thesignal has a duration of 25 usec. The action of the Transmitter drivercircuit is to alternately cause the first 170 and second 172 halves ofthe primary winding 164 to conduct a substantial current change in therespective half of the primary winding 170 or 172, resulting in areplica of the current in the secondary winding 168. The voltageappearing across the secondary winding 168 is stepped up according tothe ratio of the number of turns in the secondary winding 168 to thenumber of turns in the first primary winding. In this illustrativeexample, the turns ratio of the secondary winding 168 to each of thefirst primary windings 170 or 172 is 390 turns to 39 turns, or, 10-to-1,at any given instant because at each instant, only half of the firstprimary winding 164 is conducting current, since one of the transistors180, 182 is not conducting.

The transmitter driver circuit 160 includes a clamping circuit thatutilizes the second primary 166 to inhibit the drive current in thefirst primary 164 when it is not necessary to provide a drive signal tothe transformer. It will be recalled that the drive signal burst isissued to the transducer at 50 millisecond (msec) intervals, that is, ata 20 Hz repetition rate. Three cycles of the drive signal Vin 202 takeonly 150 usec of time. The rest of the synchronization cycle time, 49.85msec, the transmitter is required to be idle. To ensure that thiscondition is satisfied in the transmitter, a clamping signal, calledVdamp 204 is applied to the second primary winding 166 of thetransformer 162. The second primary winding 166, in the illustrativeembodiment is formed of 39 turns. The drain terminals of the third 190and fourth 192 MOSFET transistors, both N-type, are connectedrespectively to the ends of the primary winding 166. The sourceterminals of both transistors 190 and 192 are connected to a commonterminal 198, which is connected to the ground side of the circuit.

A clamp signal Vdamp 204 coupled to the clamp circuit portion of thetransmitter driver circuit 160 in FIG. 8 is applied to third 194 andfourth 196 terminals, respectively coupled to the gate terminals of thethird 190 and fourth 192 transistors. The Vdamp 204 signal, applies afalling edge at the instant the third cycle of the Vin signal 202 burstis required to end, i.e., 150 usec after the first rising edge of theVin signal 202 is applied to the first 184 and second 186 terminals.Thus, the Vdamp signal 204 ensures that the current in the first primary164 is forced to zero by the counter action of the opposite polarity ofthe damping current in the second primary 166. By the action of the stepup transformer, the transmitter driver signal applied to the transducer200 is the signal Vout 206, shown in FIG. 8 as an oscillatory waveformof the same frequency as the input burst, Vin. The amplitude of Vout issustained at approximately 1200 Volts peak-to-peak for approximatelythree cycles (150 usec) before decaying toward zero. The Vout=1200 Voltsp-p corresponds to approximately 30 joules energy in the illustrativeembodiment and is sufficient to drive the transducer portion of thetransmitter, wherein the transducer employs the segmented constructionaccording to the present invention.

Referring to FIG. 9, there is illustrated a block diagram of the controlboard portion of the block diagram of FIG. 7. The control board 220(shown as control board 132 in FIG. 7) includes in the illustrativeembodiment a programmable system on a chip (PSOC) that preferablyincludes a field programmable gate array 222 (FPGA 222) therewithinhaving an embedded processor 224. The FPGA 222 is configured to providedigitizing input logic 226 and digitizing output logic 228. Thus, theFPGA 222 should include sufficient logic elements, embedded memory andthe capability to interface with a variety of I/O requirements in a widevariety of applications that must operate in severe environmentalconditions. The embedded processor 224 within the FPGA 222 is configuredto provide all of the necessary control programming of the functionsperformed in the acoustic instrumentation portions of the cement bondlogging (CBL) tool 10, including the aforementioned transmitter controlsignals for the frequency and rate of the drive signals applied to thetransmitting transducer (See FIGS. 7 and 8 and the accompanying detaileddescription). The embedded processor 224 is further configured tointerface with external memory 230 via the bus 232 and with the 10:1multiplexer (MUX) 246 via the line 248.

The embedded processor 224 also provides control for digitizing inputlogic 226 and digitizing output logic 228. The digitizing input logic226, which may operate up to 24 MHz in the illustrative embodiment,interacts with an analog-to-digital converter (A/D) 240 via address 242and data 244 lines. The digitizing input logic 226 further interactswith the external memory 230 via a read/write line (RIW) 234 and a databus 236, and receives analog signal inputs from the 10:1 MUX 246. TheMUX 246 receives the amplified receiving transducer signals from the CBLtool 10 and distributes them to the A/D 240 for sampling and digitizingprior to storage in the external memory 230.

Inputs to the analog input section 250 at terminal 254 include thesignals from ten channel inputs: eight from the individual sectors ofthe near (3′) receiver 22, one composite signal from the near (3′)receiver 22 itself, and one input from the far (3′) receiver 24. In thisembodiment, only ten of the available twelve channels are used.Referring back to FIG. 1, the 3′ receiver 22 and the 3′ receiver 24 areshown in their relative positions in the cement bond logging tool 10.The arriving signals typically have an amplitude of +/−0.5 Voltspeak-to-peak (0.5 Vp-p) and, after passing through a low pass filterhaving a 30 KHz cut-off frequency in this illustrative embodiment, areamplified in a preamplifier section of the analog input 250 to a swingof +/−1.5 Vp-p and transposed to a reference level of approximately +2.5V DC. In the preamplifier section of the analog input 250, the nominalgain applied to the signals is approximately A=3. However, this gainvalue is a typical value for purpose of illustration and actual systemsmay differ depending upon the design and intended application.

The A/D 240 in the illustrative embodiment operates at a frequency of 24MHz and is configured to digitize twelve arriving input channels at asampling rate of 12 MHz. Thus, each channel is sampled and digitized ata 1.0 MHz rate, i.e., 1.0 usec per sample. In the system illustratedherein, each waveform is sampled 250 times—digitizing approximately fivecycles of a 20 KHz signal. If eight sector signals are digitized, thetotal time required is 8×250 usec=2000 usec=2.0 millisec. Further, 1100usec are allocated to digitize the outputs of each of the 3′ and 3′receivers. Thus, the total time to sample and digitize the ten channelsof information (note that two channels are not used in this illustrativeexample) during each 50 millisecond processing cycle is approximately4200 usec or 4.20 milliseconds. At the nominal transmitter firing rateof 20 Hz, this represents a small fraction of the time available in each50 msec., 20 Hz cycle. This ‘unused’ available time is then availablefor performing other signal processing operations in the CBL tool 10.

Continuing with FIG. 9, the digitized signals from the A/D are stored inthe memory 230 in time-mapped locations to await further signalprocessing prior to transmitting the data to the surface. The additionalsignal processing maybe performed, for example, to normalize the datausing calibration factors stored in the memory 230 during manufacture ofthe cement bond logging tool 10. The processes for performing thenormalization will be described herein below with FIG. 10. Duringoperation of the CBL tool 10, the digitizing output logic, according toaddresses transmitted along the address bus 262, controls retrieving ofthe data from the memory 230 via a 14 bit data bus 264, transferring itto the digital-to-analog controller (DAC) 260. Analog signals from theoutput of the DAC 260 are coupled along a signal line 266 to an analogoutput section 270. In the analog output section 270, the analog signalsare adjusted to a reference level and amplified to condition the signalsfor being coupled to the wire line 12 by a line driver stage (e.g., 152in FIG. 7). In an alternate embodiment, the data may be retrieved frommemory 230 and transferred in digital form to a memory module (not shownin FIG. 9, but see FIG. 7 and the accompanying description hereinabove). In this alternate embodiment, which is suited for use withlogging tools supported by the well-known “slickline,” the data is heldin the memory module for later retrieval. Also shown in FIG. 9 is apower supply 280 for providing operating voltages over lines 282 tovarious functional sections of the acoustic instrumentation within theCBL tool 10.

Referring to FIG. 10, there is illustrated a flow chart of oneembodiment of a process for normalizing a cement logging tool accordingto the present invention for use in the system of FIG. 7 using asegmented transducer such as shown in FIG. 3A. In this normalizationprocess, the digital gain factor Fc will be calculated for each of theten channels of the present illustrative embodiment for receiving inputsignals from the acoustic receiving transducers. In a CBL tool usingacoustic transducers several kinds of variables can affect the acousticsignals being transmitted, conducted, reflected, refracted and receivedin the structure of the CBL tool itself, the fluid within the wellcasing, the well casing, the cement within the bore hole between thewell casing and the formation, and the formation penetrated by the borehole.

In order to ensure that the information conveyed by the acoustic signalsreceived by the receiving transducers is referenced to standardconditions in the CBL tool, the digitized signals are normalized in thesignal processing circuitry of the CBL tool as embodied in the presentinvention. The normalization that is performed during operation of theCBL tool is carried out using calibration factors derived duringoperation of the CBL tool under free pipe conditions. The calibrationfactors are obtained during execution of the normalization programillustrated in FIG. 10, after initializing the circuitry in the CBL toolunder free pipe conditions. Free pipe conditions are simulated, beforeshipment of the tool to a customer, by placing the CBL tool in a sectionof well casing, centralizing the CBL tool body within the well casing,and filling the section of well casing with a fluid, e.g., water, underpressure. The tool is brought to operating temperature, the transmitteris excited, the tool placed in a calibration mode, and the digital gainof the digitizing circuitry for the receiver preamplifiers individuallyadjusted under to a reference value for each channel. This normalizationprocess is accomplished under program control by the high speed signalprocessing within the CBL tool, takes only a few seconds, and can beaccessed at any time to calibrate the CBL tool or for verification bythe surface operator in seconds, whether the CBL tool is suspended bythe wire line at the surface or within the well casing at any depth.

Continuing with FIG. 10, the normalization process begins at a startblock 300, followed by step 302 to set a jumper to an ON position toplace the logging tool into the calibration mode and power up thelogging tool. In the next step 304, drive is enabled to energize thetransmitter, the normalization run is set for 100 cycles or repetitions,and the channel number “m” is set to m=1. In step 306, a pre-acceptancethreshold (See the detailed description of FIG. 14, infra, for furtherexplanation of a pre-acceptance threshold) is set at an appropriatelevel above the noise, as a reference level for recognizing anacceptable positive signal output from a segmented receiving transduceror transducer sector. The steps 302 through 306 together accomplish theinitialization of the circuitry in the logging tool.

In step 308, the execution portion of the normalization process isbegun, wherein the signal is tracked, sampled at the sampling rate of1.0 MHz (12.0 MHz divided by 12 channels) and digitized. The digitizedvalue of the positive peak is then stored in the memory of the loggingtool signal processing circuitry. The step 308 is repeated apredetermined number of times; in the illustrative example, it isrepeated 80 times in step 310. The predetermined number may be at leasta majority of the number of firing cycles or repetitions to which thetransmitter is set to be energized. Then, in step 312, the stored peakvalues are sorted to provide a representative number of samples,eliminating the 20 lowest values and the 20 highest values. In thepresent example, the number of values to be eliminated is set to 25percent of the number of repetitions of the digitizing step. Theremaining 40 values, the representative samples, are averaged in step314, and the average value set equal to “N” and stored in time-mappedlocations in memory. The value “N” is the normalized peak value for theparticular channel “m” in the particular tool being calibrated.

In the following decision step 318, a query expressed as 12−m=0? isevaluated, and if the result is negative, the flow enters step 316.Steps 308 through 314 are then repeated in step 316 for the nextchannel, i.e., for m=m+1, and the flow of the process returns to beginagain with step 304. If, however, the result of the query in step 318 isaffirmative, the flow advances to step 320. In step 320, a “standard”Vin value (signifying the value of the input voltages to the surfaceinstrumentation) is selected and designated as “Vin,std.” This operationis performed, and the digital gain adjusted, so that all of the channelscan be operated to the same baseline, i.e., have the same offsetadjusted approximately to a zero value. The “zero” value corresponds toa baseline defined as: ½(Vpk-pk) for each of the channel signals. Forthe purposes of this description, the selected value for Vin,std may be4.0 Volts. This value is somewhat arbitrary, but is chosen to be largeenough to survive transmission up the sometimes very long wire line(unless the logging tool is configured for use with a slickline, inwhich case this limitation is not applicable), yet without causing theoutput driver to exceed its maximum peak-to-peak voltage swing. Invarious applications, this value maybe selected at other voltages,depending on the application.

Following selection of the value for Vin,std, step 322 performs thecalculation of a digital gain factor Fc=Vin,std divided byN for each ofthe twelve channels, using the time-mapped values for N that areassociated with each channel m=1, 2, . . . 12. Next, in step 324, thevalues for Fc for all of the channels are stored in memory in the CBLtool. These digital gain factors are then available for use anytime theCBL tool of the present invention is placed into the calibration mode.After the digital gain factors Fc are stored, the normalization routineis completed and may be exited in step 326 by restoring thenormalization mode jumper to its OFF position.

Referring to FIGS. 11A and 11B, there is illustrated a flow chart of oneembodiment of a signal processing method according to the presentinvention for use in the system of FIG. 7 using the transducer of FIG.3A. Following the start block 390, power is applied in step 392 to theCBL tool 10, and the calibration waveforms stored in the tool memory aretransmitted to the surface for display, enabling the operator tocalibrate the surface instrumentation by setting the gain reference forall of the signals received to a known value, e.g., 0.50 Volts. Thiscalibration is performed to normalize the tool to the operating depth(i.e., the length of the wire line, in the case where the data istransmitted up the wire line) and other variables of the individualsite. Applying power also enables the transmitter board (See FIG. 8described supra) to generate a plurality of 20 KHz excitation pulses instep 394 to drive the transmitter. In the illustrative embodiment, threecycles of the 20 KHz square wave signal have been found sufficientthrough experimentation to adequately excite the transmittingtransducer, causing it to output a wave train having approximately threecycles of a 20 KHz acoustic signal before becoming damped by themechanical losses in the transducer crystal material and decaying tozero. The transmitter circuit, upon receiving the three-pulse input atstep 396 responds by outputting a 20 KHz, 1200 Volt peak-to-peak signal,which is applied across the transducer, exciting it to oscillate at the20 KHz frequency in its anti-resonant mode. At approximately 200microseconds (usec) after the beginning of the three cycle excitationpulse train, step 398 starts a timer and causes the generation of a 20Hz synchronization pulse to be used by the surface instrumentation. Aswill be observed in FIG. 14 to be described, transmission of the syncpulse is delayed a sufficient amount of time following the three-cycleexcitation burst to ensure that the sync signal is unaffected by theburst signal. The sequence of acoustic signals, beginning with thetransmitting transducer sending the 20 KHz signal into the surroundings,will be illustrated in FIGS. 12 through 14 and the accompanyingdescription.

Continuing with FIG. 11A, following the generation of the 20 Hz syncpulse, the near (3′) receiver 22 (See FIG. 1) receives the acousticsignals traveling through the bore hole and the adjacent lithographyformation in step 400, and responds by outputting correspondingelectrical signals from each of the eight sectors of the receivingtransducer. These eight signals are coupled into channels 2 through 9 ofthe multiplexer 246 in the control board portion 220 (See FIG. 9) of thesignal processing section of the CBL tool 10 (See FIG. 1). Approximately100 microseconds later (the amount of the time delay, represented inFIG. 11A, is variable, depending upon the particular logging conditionsand activity), the far (5′) receiver 24 receives acoustic signals instep 402 that result from the same transmitted burst but having traveledfarther through the bore hole and the adjacent lithography. The farreceiver output signal is coupled to channel one of the multiplexer 246.Meanwhile, during the processing of the eight sector outputs of the nearreceiver, the highest peak values of the waveforms from each of theeight receiver sectors are summed in step 404 and coupled to channel tenof the multiplexer 246. The inputs to the ten channels of themultiplexer 246 are sequentially coupled to the A/D in step 406,digitized in sequence at a 12 MHz rate, and stored in a time-mappedlocation in memory. In the following step 407, the amplitude of eachsample of each signal is revised according to the calibration factor Fcthat was calculated during the normalization of the CBL tool, asdescribed with FIG. 10. The processing is momentarily idle at this point(step 408) as it awaits the next step instruction from the embeddedprocessor on the control board 220.

Referring to FIG. 11B, which is a continuation of step 11A, the embeddedprocessor 224 on the control board 220 signals the output logic and theDAC 260 to form composite data for storage in another time-mapped memorylocation in step 410. This composite data is the digital data thatrepresents the type of signals illustrated in FIG. 13 (to be described),which in turn represent the acoustic signals that convey informationabout the effects that the structures of the well and the surroundinglithography have imprinted in the acoustic signals. One important pieceof data embodied in the data is the “first arrival time,” which recordsthe first instant, relative to the sync pulse, that the first positiveportion of the signal of interest—an individual sector signal, acomposite near receiver signal, or a far receiver signal—reaches itspeak value.

Looking ahead for a moment to FIG. 13, at the center panel of the toprow of waveform panels, there is illustrated a waveform from receivingsector 1 (“WVFS1”). This is a waveform according to an industry standardpractice. The signal includes three full cycles, beginning with apositive-going excursion, followed by a damped decay from the positivealternation of a fourth cycle. The first positive peak is designated El,the first negative peak is designated E2, the second positive peak isdesignated E3, and the second negative peak is designated E4.Superimposed over the graph before and during the initial cycle of thewaveform is a low profile “goal post” outline symbol (part of agraphical user interface provided in the software of the CBL tool of thepresent invention) that includes a horizontal line (voltage marker 470)within the symbol. This voltage marker 470 is adjusted to indicate thevoltage intercept of the El peak, a value that is set comfortably abovethe noise level in the system. The peak voltage value of El is the valuethat the calibration routine adjusts the signal processing section toprovide for each channel, thereby normalizing all of the channels to thesame value. In a typical application this value of E1 maybe set toapproximately 0.75 Volts. The time intercept of the voltage intercept isindicated by a vertical line (time marker 472). The “goal post” symbolis set to begin 100 usec after the sync pulse and continue until thetime marker 472. Time marker 472 provides a clearly distinguished “firstarrival time” indicator to the surface operator.

Returning to the description for FIG. 11 B, the “first arrival time” iscalculated in step 412, after the digitized data is retrieved frommemory. This instant in time occurs typically approximately 270microseconds after the sync pulse, corresponding to the arrival of thesignals sensed by the near receiver 222. As would be expected, the farreceiver signals arrive somewhat later, corresponding to the two-footgreater distance from the transmitter to the far receiver 24.The signalfrom the far receiver 224 arrives approximately 115 microseconds afterthe near receiver signals.

Continuing with FIG. 11 B, After the first arrival time is calculated,the data is normalized, then decoded in the DAC 260, in step 414 usingthe stored calibration signals retrieved from the memory in the tool, asdescribed with FIG. 10 herein above. In the next step 416, the analogoutputs from the DAC are sent to the analog stage 270 for amplificationand conditioning to prepare them for coupling to the output (line)driver 152, or to the memory module 153, in step 418 (See also FIG. 7).The line driver processes the data for display at the surface in step420 and transmits the analog data signals thereto. In the followingstep, 422, the routine ends and the control board 220 in the CBL toolreturns the routine to the entry point at step 390 to await the nextsync pulse.

Referring to FIG. 12, there is illustrated an amplitude vs. time graphof the complete sequence of signal outputs occurring in each 50millisecond interval from the segmented transducers according to thepresent invention. The complete sequence 440 begins with the sync pulse446, followed by the composite waveform 448 of the far (5′) receiver (24in FIG. 1). Following the start of the 5′ receiver signal 448, atintervals of approximately 3.2 milliseconds, are the eight respectiveoutput signals of the eight sectors of the near (3′) receiver (22 inFIG. 1). Waveform 450 is the first sector output, 452 the second sectoroutput, 454 the third, and so on to waveform 464, which is the eighthsector output waveform. Next appears the composite waveform 466 of thenear (3′) receiver 22 output, followed by a calibration signal 468. Itwill be observed in FIG. 12 that the time elapsed from the sync pulse446 to the calibration signal 468, indicated in the figure by the longerbracket 442, is just under 32 milliseconds. The remaining time withinthe 50 millisecond period of the 20 Hz data transmission cycle isapproximately 18 milliseconds, part of which is represented by theshorter bracket 444 in the figure, to provide time for transmitting datafrom other instruments in the CBL tool. In FIG. 12, for example, sometelemetry signals conveying other data are shown within the bracketedinterval 444 indicated after the calibration signal 468.

Referring to FIG. 13, there is illustrated a set of output waveformgraphs from a single GUI display of the far receiver (WVF5FT), the eightradial sectors of the near receiver (WVFS 1, 2, . . . , 8), the nearreceiver (WVF3FT), and the calibration signal (WVFCAL) from a CBL toolusing the segmented transducers according to the present invention. Thesequence of waveform panels begins with the composite waveform 448 ofthe far (5′) receiver at the upper left corner of FIG. 13. Following the5′ receiver signal 448 are the eight individual output signals of theeight sectors of the near (3′) receiver. Waveform 450 is the firstsector output, 452 the second sector output, 454 the third, and so on towaveform 464 , which is the eighth sector output waveform. Next appearsthe composite waveform 466 of the near (3′) receiver output, followed bythe calibration signal 468.

As described previously with FIG. 11B herein above, superimposed overthe graphs in each of the waveform panels of the display, before andduring the initial cycle of the waveform, is the low profile “goal post”outline symbol of the graphical user interface provided in the softwareof the CBL tool. The “goal post” symbol includes the horizontal linevoltage marker 470 within the symbol. This voltage marker 470 isadjusted to indicate the voltage intercept of the positive-going portionof the El peak, a value that is set comfortably above the noise level inthe system. Just above the voltage intercept is the peak voltage valueof El. The peak voltage value is the value that the calibration routineadjusts the signal processing section to provide for each channel,thereby normalizing all of the channels to the same value. In a typicalapplication this value of E1 may be set to approximately 0.75 Volts. Thetime intercept of the voltage intercept is indicated by a vertical line(time marker 472). The “goal post” symbol is set to begin 100 usec afterthe sync pulse and continue until the time marker 472. Time marker 472provides a clearly distinguished “first arrival time” indicator to thesurface operator.

In the GUI of FIG. 13, as actually displayed on a computer screen, thevoltage marker 470 and the time marker 472 may be in a color differentthan the waveform in order to distinguish them. Similarly, the firstcycle of the waveform, or a substantial portion thereof, may be shown ina third color to enable easier recognition. In FIG. 13, this earlyportion of the waveform is shown as a thinner, dashed line todistinguish it from the waveform drawn in a heavy, continuous line.Further, the “goal post” symbol may be high lighted by a fourth color orshading, or merely outlined by a thin line as shown in FIG. 1.

Continuing with FIG. 13, the same GUI features described in thepreceding paragraph are employed in all of the panels of the GUI displayillustrated in FIG. 13. In the lower portion of each panel, in two linesof characters, is some additional numerical information about thewaveform related to the “goal post” symbol. In the upper line are (a)the first arrival time; (b) the intercept voltage; and (c) the number ofwaveform data cycles per second, e.g., 20/s, corresponding to 20 datacycles per second, or 20 Hz. In the lower line is a statement about the“travel time” interval (TT GATE) covered by the “goal post” symbol, inthe form: start time—end time (duration) and the threshold voltage. Thethreshold voltage is the height, in millivolts, of the voltage markerline 470 described previously. The three time values are given inmicroseconds.

The display illustrated in FIG. 13 enables the surface operator toquickly observe the status of all of the cement logging signals sent tothe surface instrumentation, along with the calibration pulse forsupplying information about the reference used by the tool at the timeof the logging is performed. Typically, the far (5′) receiver outputWVF5FT (waveform 448) is sent to channel one and therefore appears firstat the top left corner of the display, followed by, proceeding from leftto right, top to bottom, the eight waveforms WVFS1, 2, . . . , 8(waveforms 450 through 464). In the lower left corner of the displayappears the near (3′) receiver waveform 466 that is a composite of allof the peak values of the individual sectors. The near receiver waveform466 is shown having greater variability in the amplitudes of theindividual alternations of the signal.

The variability of the amplitudes of the peak values of the far and nearreceiver waveforms, respectively 448 and 466, may be caused by manyfactors. As is well known, sound travels through substances in severalforms. Compressional (“P”) waves cause the molecules of the substance tovibrate in the direction of propagation through the substance(“longitudinally”) with high velocity and relatively low energy. Shear(“S”) waves cause the molecules of the substance to vibrate normal tothe direction of propagation with lower velocity but higher energy thanP waves. Further, shear waves, because liquids and gases have no shearstrength, may travel in solid substances but not liquids or gases.Another type of wave form, not fully understood, is a Stonely wave (akaa “tube” wave) that travels along a liquid/solid interface or boundary.Since these various wave forms propagate or travel at variousvelocities, their arrival time at a given point will generally also varydepending on the nature and type of substance. Other factors may affectthe amplitude, phase, and velocity of the sound signal as it ispropagated from the transmitter to the receivers. Given this variety ofinfluences, it is readily appreciated that the output waveforms providedby the receiving transducers are subject to substantial variability.Moreover, interpretation of the transducer waveforms is a complextechnical task that is beyond the scope of this detailed description ofthe present invention. Briefly, and in general, the first portion of thetime period during the receipt of an acoustic signal by a receivingtransducer, the wave type is compressional, followed by shear waves,compressional waves in fluids, Stoneley waves, etc. The amplitudes ofthese composite signals representing several properties of the wellenvironment and the formation containing the well will vary as describedherein above. It is these kinds of influences which cause the variationsthat appear in the near and far receiver waveforms illustrated anddescribed herein.

Referring to FIG. 14, there is illustrated an amplitude vs. time graphof the time relationship of the excitation of the transmittingtransducer, the sync pulse preceding transmission of the data to thesurface, and the near (3′) and far (5′) receiving transducers of a CBLtool using the segmented transducers according to the present invention.It should be recalled that the operating frequency of the acoustictransducers in this illustrative embodiment is 20 KHz, that is, thetransmitting transducer is excited by a plurality of cycles of a 20 KHzsquare wave. In the example described herein, this excitation signal 480is a three-cycle burst as shown at the left of the center waveform graph(line 1). The excitation signal 480 is followed approximately 100microseconds later by the synchronization signal 482, which is a singlepulse of approximately 20 microseconds duration, repeated at a 20 Hzrate or every 50 milliseconds to control the timing of the signalprocessing cycles. The signal levels on line 1 are otherwise quiescent,except for the system noise level represented by the very smallamplitude variations present at the base line, until the next excitationsignal 50 microseconds after the preceding one, etc. It will be observedthat the system noise also appears on the peak portions of the signals.

Lines 2 and 3 on the graph of FIG. 14 illustrate the early portions oftypical waveforms of the near (3′) 484 and far (5′) 486 receiversrespectively. Of interest in these examples are the clear definition,robust amplitude, and the substantial signal-to-noise ratio of thewavefroms of both receivers. These qualities are provided by severalfeatures of the present invention, including the segmented configurationof the transducers, the multiple burst excitation of the transmittingtransducer, and the high speed digital signal processing employed in theCBL tool that uses the built-in calibration signals to calibrate thetool and normalize the received signals before transmitting them to thesurface. Further, the relative timing of the near receiver waveform 484,approximately 270 microseconds after the rising edge of the sync signal482, is clearly shown. Similarly, the far receiver waveform 486 is seento appear approximately 115 microseconds after the near receiverwaveform, and 385 microseconds after the rising edge of the sync signal482.

FIGS. 15A, 15B, and 15C illustrate a typical VDL (“Z axis” plot) for aCBL tool embodying the present inventions in FIG. 15A together with acorresponding cement map in FIG. 15B, wherein different colors orshading densities represent different cement densities. Further, anamplitude vs. time graph is shown in FIG. 15C of the signal representingthe density information of FIG. 15B. The three figures illustratedifferent but corresponding presentations derived from the same data.The illustrations are of a small portion—approximately 200 feet of depthin a well that is much more than 7000 feet deep—of an entire graphicaldisplay or print out of data. FIG. 15A illustrates the well knownvariable density log (VDL) display derived from the transducer outputsignals as previously described with FIGS. 5A and 6A. As noted with FIG.6A, the graph in FIG. 15A is characterized by substantial completenessand clarity resulting from the clear definition, robust amplitude, andsubstantial signal-to-noise ratio of the transducer output signals.These qualities enable faster and more accurate interpretation of thedata conveyed by the transducer output signals.

Continuing with FIG. 15B, a cement map is portrayed. Wherein the usualrepresentation of the degree of bonding of the cement to the well casingis represented by variations in the color of the display, the depictionin the figure is simulated by representing the color variations asvariations in the shading density or gray scale as printed in the blackand white drawing. Region 490, representing a bright blue colorcorresponding to free pipe, that is, well casing pipe in which there islittle or no cement bonded to the pipe, is shown as a medium densityshading. Region 492, representing a black color corresponding to asubstantially complete bonding of the cement to the pipe, is shown as aheavy density shading. Region 494, representing a yellow colorcorresponding to light-to-moderate bonding of the cement to the pipe, isshown as a light density shading. Region 496, representing a brown colorcorresponding to mostly complete bonding of the cement to the pipe butwith some voids in the bond, is shown as a moderately dense shading.

In FIG. 15C, a simplified graph of the cement bond level or quality,represented by the amplitude of a signal 498 relative to a base line 497is shown. Along the graph 498, the cement bond levels described for FIG.15B are marked with the same reference numbers in FIG. 15C. Thus, cementbond levels 490, 492, 494, and 496 are shown in FIG. 15C along the graph498, corresponding to the shading densities identified with the samereference numbers in FIG. 15B. Thus, a free pipe condition, with littleor no cement bonding, is represented by a high amplitude of the graph498 relative to the base line 497 at the location 490. Similarly, afully bonded pipe is represented by a low amplitude of the graph 498relative to the base line 497 at the location 492, a partly bonded pipeis represented by a moderately high amplitude of the graph at thelocation 494, and a moderately well bonded pipe is represented by amoderately low amplitude of the graph at the location 496. Thesimplified graph 498 represents a nominal presentation, combining theindividual graphs of eight sectors of the receiving transducer. Inpractice, the individual sectors may indicate substantial variation inthe cement bonding around the circumference of the well casing pipe. Thedashed line depicts one example of some variations in the cement bondingthat may appear in a typical graph form of the cement map display.

The piezoelectric transducer configuration of the present inventiondisclosed herein provides an axially segmented (divided along planesperpendicular to the longitudinal axis) transducer for transmitting orreceiving applications. The transducer is constructed of adjoiningcylindrical bands or rings separated by resilient gaskets such as “O”rings and formed into a cylindrical transducer assembly of a lengthsimilar to the conventional transducers of like application in cementbond logging tools intended for use in well casings of similar diameter.This segmented configuration enables each of the transducer elements,being much smaller, to resonate at correspondingly higher frequencies,leaving the lower frequency ranges from, for example but not limited to5 KHz to 50 KHz, free of unwanted spurs, and sub-harmonics or harmonicsof the driving frequency.

When operated at the typical 20 KHz frequency, the transducer operatesin an anti-resonant mode that is free of the interference, distortionand poor signal-to-noise ratio typically encountered with theconventional unsegmented resonators. Moreover, the capability ofoperation in the anti-resonant mode permits other frequencies to beutilized with the same transducer, or the use of the anti-resonanttransducer to be used in other logging instruments in the same loggingtool. This versatility thus enables other properties in the well casingenvironment to be measured at the same time as the cement bond loggingoperation is being performed. To achieve adequate signal levels, theplurality of piezoelectric elements assembled to construct thetransmitting transducer are driven in parallel at greater energy bymultiple pulses. Moreover, the receiving transducer is comprised ofmultiple segments assembled on the same mandrel and electrically drivenin parallel by the same impinging acoustic signal.

The segmented transducer design of the present invention enablessubstantial improvements in the performance of acoustic logginginstrumentation such as the exemplary cement bond logging tool describedherein above. When combined with the advanced digital signal processingand the normalization and calibration methods as disclosed for theexemplary cement bond logging tool herein, the segmented transducerprovides a number of advantages.

For example, the present invention provides and transmits the data inreal time during each logging cycle at 20 times per second. In contrast,conventional tools require six such logging cycles to send complete datafor both receivers because they are able to send only ⅓ of the data foreach receiver during a logging cycle. Thus the present inventionprovides the data six times as fast as a conventional cement bondlogging tool.

Further, since the present invention can fully process the data sorapidly in real time at each cycle, enabling the data itself to be takenin a few milliseconds of each 50 millisecond cycle, the data ‘package’is effectively a snapshot at a substantially stationary depth level inthe well casing for all eight sectors of the receiver, rather thanobtaining the data for each sector in a helical path around the wellcasing as the cement bond logging tool is pulled toward the surface.

Further, because of the high speed digital signal processing, thelogging tool can be pulled toward the surface at a much higher rate,completing the logging operation in much less time, for example, up to150 feet per minute. In contrast, the conventional cement logging toolis limited to rates of 30 feet to 70 feet per minute, with some beingcapable of up to 100 feet per minute.

Moreover, the cement bond logging tool of the present invention includesits own calibration factors stored in memory, enabling the tool torecalibrate itself digitally, on site, in one operation, in less than 15seconds. With this feature, there is no need to individually—and ofteniteratively, in a tedious, time consuming process for the conventionallogging tools—adjust the analog preamps every time the tool is used ormoved, or removed from the well casing. As a result of the built-incalibration process, all of the data is normalized in the tool to freepipe conditions in real time, as the data is processed beforetransmitting it to the surface during the logging operation. Thecalibration of the tool constructed in accordance with the presentinvention is performed with the tool in position in the well casing orin free air before the tool is lowered into position. These attributesof the present invention enable substantial savings of time in on-siteoperations.

All of the foregoing advantages result from the ability built into thecement logging tool to perform high speed digital signal processing inthe tool in real time at temperatures up to 400 degrees Fahrenheit and25,000 psi, performance heretofore not available in cement bond loggingtools. Further, in combination with the axially or longitudinallysegmented piezoelectric transducer configuration that is operated in ananti-resonant mode and excites the transmitter transducer with multiple,high energy drive pulses, the data provided has a substantially greatersignal-to-noise ratio and significantly improved definition of thesignals corresponding to the quality of the cement bond and of thelithology of the terrain surrounding the bore hole. The results areclearly manifest in the cleaner and more informative VDL plots andcement maps provided by the data from the instrumentation.

While the invention has been shown in only one of its forms, it is notthus limited but is susceptible to various changes and modificationswithout departing from the spirit thereof.

1. A method for processing electrical signals produced by an acousticreceiver in a logging tool, comprising the steps of: providing in thelogging tool a transmitting transducer and a longitudinally segmentedacoustic receiving transducer having a plurality of band-like transducerrings of equal diameter assembled into a cylindrical form and having anoutput, wherein each adjacent pair of transducer rings is separated by acircular resilient gasket disposed between corresponding adjacent edgesthereof; issuing synchronizing pulses to the longitudinally segmentedreceiving transducer at a predetermined repetition rate; and processingoutput signals of the longitudinally segmented receiving transduceron-depth and in real time for a full set of azimuths at each depthassociated with a successive repetition of the synchronizing pulses. 2.The method of claim 1, further comprising the step of: pulling thelogging tool toward the surface at a predetermined rate of at least 30feet per minute.
 3. The method of claim 1, further comprising the stepof: pulling the logging tool toward the surface at a predetermined rateof at least 100 feet per minute.
 4. The method of claim 1, wherein thestep of providing comprises the steps of: providing a first receivingtransducer displaced approximately three feet along a longitudinal axisfrom the transmitter transducer; and providing a second receivingtransducer displaced along the longitudinal axis approximately five feetfrom the transmitter transducer opposite the first receiving transducerfrom the transmitter transducer; wherein the second receiving transduceris configured as a longitudinally segmented receiving transducer.
 5. Themethod of claim 1, wherein the step of issuing comprises setting thepredetermined repetition rate at approximately 20 KHz.
 6. The method ofclaim 1, wherein the step of issuing comprises setting the predeterminedrepetition rate at a frequency greater than 10 KHz.
 7. The method ofclaim 1, wherein the step of processing further comprises the steps of:summing the output signals of each of the receiving transducer rings inparallel; sampling and digitizing the summed output to produce digitizedwaveform data; storing the digitized waveform data in a memory in thelogging tool; and performing output pre-processing of the digitizedwaveform data retrieved from the memory in the logging tool.
 8. Themethod of claim 7, wherein the step of performing further comprises thesteps of: extracting the digitized waveform data from the memory in thelogging tool; normalizing the digitized waveform data according tocalibration data stored in the memory of the logging tool; convertingthe normalized data to serial, analog form; and transmitting the analogdata to surface instrumentation.
 9. The method of claim 8, wherein thestep of normalizing comprises the steps of: initializing circuitry inthe logging tool for executing a normalization program upon apredetermined sequence of transmitter excitation signals; executing thenormalization program to produce digital gain factors based on anaverage value N of a plurality of representative samples of a receivedsignal; and obtaining a digital gain factor for use with each channel ofthe logging tool signal processing circuitry.
 10. The method of claim 9,wherein the step of initializing comprises the steps of: causing thecircuitry in the logging tool to enter a calibration mode; enablingexcitation signals to the transmitter for a predetermined number offiring cycles for each channel m provided in the signal processingcircuitry; and setting a signal peak acceptance threshold.
 11. Themethod of claim 10, wherein the predetermined number of firing cycles isset to 100 cycles.
 12. The method of claim 9, wherein the step ofexecuting comprises the steps of: digitizing a predetermined number ofreceived signals and storing peak values of the digitized receivedsignals in memory; sorting the stored peak values according to apredetermined criteria to provide a set of representative samples;averaging the set of representative samples to provide the average valueN; and repeating the step of executing for remaining channels of thesignal processing circuitry.
 13. The method of claim 12, wherein: thepredetermined number of received signals is set to at least a majorityof signals received during a firing cycle; and the predeterminedcriteria includes eliminating an equal percentage of highest valued andlowest valued representative samples.
 14. The method of claim 13,wherein: the predetermined number is equal to 80 percent of the numberof firing cycles; and the equal percentage predetermined for thecriteria is set to 25 percent.
 15. The method of claim 9, wherein thestep of obtaining comprises the steps of: selecting a standard value fora received input signal, Vin, std.; calculating a digital gain factorFc=(Vin,std.) divided by N; and storing values for Fc for all channelsin a memory in the logging tool.
 16. The method of claim 7, wherein thestep of performing further comprises the steps of: extracting thedigitized waveform data from the memory in the logging tool; normalizingthe digitized waveform data according to calibration data stored in thememory of the logging tool; and storing the normalized data in digitalform in non-volatile memory for subsequent retrieval.